The Industrial Revolution improved both productivity and living standards, and fossil fuels have been used as the essential energy sources for human society. However, the resultant enormous consumption has induced serious environmental and energy issues. An increase in world population and an economic growth of developing countries have accelerated the consumption of the resources. Consequently, a new energy system independent of fossil fuels must be urgently developed1). Hydrogen has been widely considered as an alternative energy source since the commercialization of fuel cells. Hydrogen is presently produced by the reforming of fossil fuels. Thus, application of renewable energy to hydrogen production is required for the reduction of the dependence on fossil fuels. However, areas optimum for solar and wind energy production are often far from energy consumption areas, although present policies depend greatly on renewable energy for the realization of a low-carbon society. Therefore, conversion of these renewable energies to hydrogen is also desirable in terms of utilization on a large scale. Hydrogen has low boiling point and volumetric energy density, leading to great difficulties in the liquefaction and compression processes. Therefore, hydrogen carrier, compounds containing hydrogen, are possible solutions for the storage and transportation of hydrogen fuel. Such hydrogen carriers can be delivered to energy consumption areas, and reformed or decomposed to produce hydrogen2). Ammonia, methylcyclohexane, and methane are all potential candidates for hydrogen carriers because of the high hydrogen content, suitability for mass production, and ease in storage and transportation2). We have focused on methane synthesis from CO2 and hydrogen, and hydrogen production by ammonia decomposition. This review mainly introduces our recent research on these reactions using supported Ni catalysts.
{"title":"Production and Utilization of Hydrogen Carriers by Using Supported Nickel Catalysts","authors":"H. Muroyama, T. Matsui, K. Eguchi","doi":"10.1627/JPI.64.123","DOIUrl":"https://doi.org/10.1627/JPI.64.123","url":null,"abstract":"The Industrial Revolution improved both productivity and living standards, and fossil fuels have been used as the essential energy sources for human society. However, the resultant enormous consumption has induced serious environmental and energy issues. An increase in world population and an economic growth of developing countries have accelerated the consumption of the resources. Consequently, a new energy system independent of fossil fuels must be urgently developed1). Hydrogen has been widely considered as an alternative energy source since the commercialization of fuel cells. Hydrogen is presently produced by the reforming of fossil fuels. Thus, application of renewable energy to hydrogen production is required for the reduction of the dependence on fossil fuels. However, areas optimum for solar and wind energy production are often far from energy consumption areas, although present policies depend greatly on renewable energy for the realization of a low-carbon society. Therefore, conversion of these renewable energies to hydrogen is also desirable in terms of utilization on a large scale. Hydrogen has low boiling point and volumetric energy density, leading to great difficulties in the liquefaction and compression processes. Therefore, hydrogen carrier, compounds containing hydrogen, are possible solutions for the storage and transportation of hydrogen fuel. Such hydrogen carriers can be delivered to energy consumption areas, and reformed or decomposed to produce hydrogen2). Ammonia, methylcyclohexane, and methane are all potential candidates for hydrogen carriers because of the high hydrogen content, suitability for mass production, and ease in storage and transportation2). We have focused on methane synthesis from CO2 and hydrogen, and hydrogen production by ammonia decomposition. This review mainly introduces our recent research on these reactions using supported Ni catalysts.","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"96 1","pages":"123-131"},"PeriodicalIF":1.0,"publicationDate":"2021-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74048489","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Kojima Keisuke, K. Okamura, M. Tasaki, M. Sueyoshi, R. Al-Maamari
Treatment of oily wastes generated in production and refining processes is one of the major environmental issues facing the petroleum industry in oil producing countries. Oily wastes such as crude oil storage tank sludge and oil-based drilling mud contain various hazardous materials such as oil (petroleum hydrocarbons) and heavy metals. Generation of oily waste is increasing, and combined with the processing cost and capacity limitations of currently available treatment technologies, is resulting in the accumulation of large amounts of untreated oily waste1). Consequently, inexpensive and effective treatment methods are now needed. Various technologies have been investigated for the treatment of oily wastes. Solvent extraction2),3) has high oil removal efficiency, and allows oil recovery, but the cost is very high and so is considered to be impractical. Biological treatment methods4)~7) capable of large-scale treatment such as land farming can be implemented at low cost, but the treatment period is lengthy and the space requirement is large. Additionally, some oily wastes such as crude oil storage tank sludge contain resin and asphaltene that is difficult to treat biologically. Thermal decomposition treatment8),9) such as carbonization has high oil removal capability and also allows oil recovery, so development continues as a promising technology. For example, addition of various catalysts improves the oil recovery amount and recovered oil quality, resulting in decreased overall treatment cost10)~14). However, the properties of oily wastes can vary greatly by location and over time1),15), so thermal decomposition treatment using a catalyst must adapt the optimum conditions, such as catalyst type and addition amount, to the properties of the oily waste to be treated. This study investigated carbonization treatment (pyrolysis) using superheated steam, without any catalyst, to remove oil from waste. Superheated steam is generated under the operating pressure (steam at 100 °C under normal pressure) and further heated to a temperature higher than the boiling point. This superheated steam heats anoxically, as heat is directly applied without air. Air heating acts only by convection, whereas superheated steam has very high heat energy that can be transferred by condensation and radiation, as well as convection, resulting in superior heat efficiency compared to air heating. In an earlier study16), carbonization treatment using superheated steam removed oil concentrations in waste [Regular Paper]
{"title":"Treatment of Oily Waste Using a Scaled-up Carbonization Kiln","authors":"Kojima Keisuke, K. Okamura, M. Tasaki, M. Sueyoshi, R. Al-Maamari","doi":"10.1627/JPI.64.137","DOIUrl":"https://doi.org/10.1627/JPI.64.137","url":null,"abstract":"Treatment of oily wastes generated in production and refining processes is one of the major environmental issues facing the petroleum industry in oil producing countries. Oily wastes such as crude oil storage tank sludge and oil-based drilling mud contain various hazardous materials such as oil (petroleum hydrocarbons) and heavy metals. Generation of oily waste is increasing, and combined with the processing cost and capacity limitations of currently available treatment technologies, is resulting in the accumulation of large amounts of untreated oily waste1). Consequently, inexpensive and effective treatment methods are now needed. Various technologies have been investigated for the treatment of oily wastes. Solvent extraction2),3) has high oil removal efficiency, and allows oil recovery, but the cost is very high and so is considered to be impractical. Biological treatment methods4)~7) capable of large-scale treatment such as land farming can be implemented at low cost, but the treatment period is lengthy and the space requirement is large. Additionally, some oily wastes such as crude oil storage tank sludge contain resin and asphaltene that is difficult to treat biologically. Thermal decomposition treatment8),9) such as carbonization has high oil removal capability and also allows oil recovery, so development continues as a promising technology. For example, addition of various catalysts improves the oil recovery amount and recovered oil quality, resulting in decreased overall treatment cost10)~14). However, the properties of oily wastes can vary greatly by location and over time1),15), so thermal decomposition treatment using a catalyst must adapt the optimum conditions, such as catalyst type and addition amount, to the properties of the oily waste to be treated. This study investigated carbonization treatment (pyrolysis) using superheated steam, without any catalyst, to remove oil from waste. Superheated steam is generated under the operating pressure (steam at 100 °C under normal pressure) and further heated to a temperature higher than the boiling point. This superheated steam heats anoxically, as heat is directly applied without air. Air heating acts only by convection, whereas superheated steam has very high heat energy that can be transferred by condensation and radiation, as well as convection, resulting in superior heat efficiency compared to air heating. In an earlier study16), carbonization treatment using superheated steam removed oil concentrations in waste [Regular Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"48 1","pages":"137-146"},"PeriodicalIF":1.0,"publicationDate":"2021-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79854152","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Natural gas hydrates are crystalline solids composed of water and gas1). Gas molecules, such as methane, are trapped in cavities composed of hydrogen-bonded water molecules. Natural gas hydrates have been a subject of concern for the natural gas industry from 1930s due to their role as a cause of flow assurance failure. Conversely, from 1960s onward, methane hydrate discovered in the Arctic, together with deep water environments, has offered both a means of determining past and future climate change and a potential energy resource, since a large fraction of the Earth’s fossil fuels is considered to be stored in hydrates2). Present estimates of global hydrate-bound methane in nature are on the scale of at least 3000 trillion m3 (1.5×103 Gt of carbon)3). Large volumes of methane hydrate exist in oceanic environment. Until the late 1990s, oceanic gas hydrates were thought to exist primarily in low permeability, unconsolidated muds; however, extensive methane hydrate deposits were discovered in sand reservoirs at the Nankai Trough off the coast of Japan in 19994). Methane hydrate accumulating in sand reservoirs at high saturation appears to be a promising energy resource because its greater permeability enables hydrate dissociation and gas production by using systems of the oil and gas industry3). Following this discovery, methane hydrates in marine sands have received widespread attention as an alternative natural gas resource. Recent studies have indicated that the amount of gas-in-place in global gas hydrates in sand reservoirs is in the order of 300 trillion m3 (1.5×102 Gt of carbon)3). To date, Japan and China have performed offshore methane hydrate production tests in the eastern Nankai Trough and South China Sea, respectively. The world’s first offshore production test in 2013 and the second production test in 2017, both at the eastern Nankai Trough, confirmed continuous gas production from oceanic methane hydrate accumulated in a sand (fine [Review Paper]
{"title":"Methane Hydrate in Marine Sands: Its Reservoir Properties, Gas Production Behaviors, and Enhanced Recovery Methods","authors":"Y. Konno, J. Nagao","doi":"10.1627/JPI.64.113","DOIUrl":"https://doi.org/10.1627/JPI.64.113","url":null,"abstract":"Natural gas hydrates are crystalline solids composed of water and gas1). Gas molecules, such as methane, are trapped in cavities composed of hydrogen-bonded water molecules. Natural gas hydrates have been a subject of concern for the natural gas industry from 1930s due to their role as a cause of flow assurance failure. Conversely, from 1960s onward, methane hydrate discovered in the Arctic, together with deep water environments, has offered both a means of determining past and future climate change and a potential energy resource, since a large fraction of the Earth’s fossil fuels is considered to be stored in hydrates2). Present estimates of global hydrate-bound methane in nature are on the scale of at least 3000 trillion m3 (1.5×103 Gt of carbon)3). Large volumes of methane hydrate exist in oceanic environment. Until the late 1990s, oceanic gas hydrates were thought to exist primarily in low permeability, unconsolidated muds; however, extensive methane hydrate deposits were discovered in sand reservoirs at the Nankai Trough off the coast of Japan in 19994). Methane hydrate accumulating in sand reservoirs at high saturation appears to be a promising energy resource because its greater permeability enables hydrate dissociation and gas production by using systems of the oil and gas industry3). Following this discovery, methane hydrates in marine sands have received widespread attention as an alternative natural gas resource. Recent studies have indicated that the amount of gas-in-place in global gas hydrates in sand reservoirs is in the order of 300 trillion m3 (1.5×102 Gt of carbon)3). To date, Japan and China have performed offshore methane hydrate production tests in the eastern Nankai Trough and South China Sea, respectively. The world’s first offshore production test in 2013 and the second production test in 2017, both at the eastern Nankai Trough, confirmed continuous gas production from oceanic methane hydrate accumulated in a sand (fine [Review Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"199 1","pages":"113-122"},"PeriodicalIF":1.0,"publicationDate":"2021-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77983341","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
H. Saima, Masatoshi Todaka, Kono Tatsuya, R. Maruta, Kodai Kadota, Y. Mogi
Global warming caused by increased emissions of greenhouse gases, especially CO2, is a pressing global problem. Atmospheric CO2 concentration rose above 400 ppm1) in 2015, and continues to increase. Therefore, CO2 emissions must be drastically reduced or eliminated entirely to prevent an increase in global temperature of more than 2 K by 21002). One solution is to recycle CO2 into fuel using hydrogen produced from renewable energy sources. Previous studies have examined the synthesis of hydrocarbons such as methane, methanol, gasoline, and diesel fuel from CO2. Methane and methanol can be effectively synthesized from CO2; but the methanol yield is strongly limited by the thermodynamic equilibrium of the reaction. For example, the yield of methanol from synthesis gas at 4 MPa is only 30 % at 473 K, and 13 % at 523 K. Conversion of methanol to dimethyl ether (DME) may increase the yield of methanol and DME3). The highest yield of methanol and DME was 24 % at 543 K, achieved by combining a methanol synthesis catalyst with γ-Al2O3. Similar possibilities can be applied to the conversion of CO2 to hydrocarbons, which are currently a more important fuel. Other studies have reported hydrocarbon synthesis from syngas4)~6). Use of a combination of CuZnO and ultra-stable Y-type zeolite catalyst at 623 K and 2.1 MPa obtained a yield of hydrocarbons of 30 %, about 75 % of which were C3 and C4 paraffins, or liquefied petroleum gas (LPG). These techniques can be applied to hydrocarbon synthesis from CO2; but methanol synthesis catalysts such as CuZnOAl2O3 have low thermal stabilities at the conditions under which the zeolite catalyst actively forms hydrocarbons from methanol/dimethyl ether. Therefore, development of a new methanol synthesis catalyst with high thermal stability is required. Fine bubbles smaller than 100 μm show unique behavior. Fine bubbles have a large specific surface area, so gas molecules inside the bubble will easily and rapidly contact with the surrounding liquid. Here we describe a new method for the preparation of precipitated catalyst by passing fine bubbles through a solution. Mixed metal salts solution will quickly react with ammonia in fine bubbles but the resulting metal hydroxide is unlikely to aggregate into large particles because the precipitate is generated only at the interface of the liquid and fine bubbles. Consequently, the particle diameter of the precipitate prepared by this fine bubble method is thought to be very fine with a large specific surface area. A CuZnOAl2O3 catalyst, prepared with [Regular Paper]
{"title":"A New Method for Synthesizing Co-precipitated Cu–ZnO Catalyst and Its Activity for Methanol Decomposition at High Temperature","authors":"H. Saima, Masatoshi Todaka, Kono Tatsuya, R. Maruta, Kodai Kadota, Y. Mogi","doi":"10.1627/JPI.64.132","DOIUrl":"https://doi.org/10.1627/JPI.64.132","url":null,"abstract":"Global warming caused by increased emissions of greenhouse gases, especially CO2, is a pressing global problem. Atmospheric CO2 concentration rose above 400 ppm1) in 2015, and continues to increase. Therefore, CO2 emissions must be drastically reduced or eliminated entirely to prevent an increase in global temperature of more than 2 K by 21002). One solution is to recycle CO2 into fuel using hydrogen produced from renewable energy sources. Previous studies have examined the synthesis of hydrocarbons such as methane, methanol, gasoline, and diesel fuel from CO2. Methane and methanol can be effectively synthesized from CO2; but the methanol yield is strongly limited by the thermodynamic equilibrium of the reaction. For example, the yield of methanol from synthesis gas at 4 MPa is only 30 % at 473 K, and 13 % at 523 K. Conversion of methanol to dimethyl ether (DME) may increase the yield of methanol and DME3). The highest yield of methanol and DME was 24 % at 543 K, achieved by combining a methanol synthesis catalyst with γ-Al2O3. Similar possibilities can be applied to the conversion of CO2 to hydrocarbons, which are currently a more important fuel. Other studies have reported hydrocarbon synthesis from syngas4)~6). Use of a combination of CuZnO and ultra-stable Y-type zeolite catalyst at 623 K and 2.1 MPa obtained a yield of hydrocarbons of 30 %, about 75 % of which were C3 and C4 paraffins, or liquefied petroleum gas (LPG). These techniques can be applied to hydrocarbon synthesis from CO2; but methanol synthesis catalysts such as CuZnOAl2O3 have low thermal stabilities at the conditions under which the zeolite catalyst actively forms hydrocarbons from methanol/dimethyl ether. Therefore, development of a new methanol synthesis catalyst with high thermal stability is required. Fine bubbles smaller than 100 μm show unique behavior. Fine bubbles have a large specific surface area, so gas molecules inside the bubble will easily and rapidly contact with the surrounding liquid. Here we describe a new method for the preparation of precipitated catalyst by passing fine bubbles through a solution. Mixed metal salts solution will quickly react with ammonia in fine bubbles but the resulting metal hydroxide is unlikely to aggregate into large particles because the precipitate is generated only at the interface of the liquid and fine bubbles. Consequently, the particle diameter of the precipitate prepared by this fine bubble method is thought to be very fine with a large specific surface area. A CuZnOAl2O3 catalyst, prepared with [Regular Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"13 1","pages":"132-136"},"PeriodicalIF":1.0,"publicationDate":"2021-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73826948","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A. Yonezawa, Naoki Tanaka, Yoshiki Hayase, M. Sano, Toshimitsu Suzuki, T. Miyake
Metal-organic frameworks (MOFs)1),2) have recently attracted much attention because of their unique properties such as crystalline and microporous structure, high thermal stability up to around 400 °C, and easy modification of pore structure and chemical properties3). Generally, MOFs consist of a multi-valent metal cation or cluster at the corner position and dior tri-carboxylic acids as the bridging unit (linker)2). MOFs with desired physical and chemical properties may be designed and synthesized by combining various metal cations and linkers. MOFs with unique properties have high potential for various applications such as adsorbents, membranes, sensors, catalysts, and others. In particular, MOFs are expected to act as lightweight hydrogen storage materials4)~6) due to their extremely high specific surface areas reaching 6000 m2 g1. Recently, MOFs have been widely studied as catalysts7),8). MOFs have also been evaluated for the separation of aromatics9),10) and aliphatic hydrocarbons11),12). p-Xylene is an important raw material for terephthalic acid, the co-monomer for polyethylene terephthalate. Nowadays, p-xylene is produced by separation from the xylene mixture by adsorption with zeolite13) or crystallization14). In the former method, xylenes diffuse into the micropores of zeolite and separation of p-xylene is based on the adsorption stability in the micropores. Multiple adsorption columns are needed for effective separation, and the feed flow is changed by the operation of many valves systematically (pseudo-transfer bed separation). Consequently, the separation process is complicated and the equipments are costly. In contrast, separation by crystallization necessitates heating and cooling of the vessel and so the energy consumption is high. Therefore, a new process to separate p-xylene at lower cost is very desirable. MOFs have been investigated for the separation of xylenes15)~25). In most cases, xylenes diffused into the micropores and separation was governed by the diffusion rate based on the molecular size of xylenes or by interactions between the MOF surface and xylenes. The separation mechanism is similar to that of the conventional process using zeolite, so the required volume of adsorbent is large because all the xylene substrate [Regular Paper]
{"title":"Molecular-sieving Separation of p-Xylene with Metal-organic Frameworks","authors":"A. Yonezawa, Naoki Tanaka, Yoshiki Hayase, M. Sano, Toshimitsu Suzuki, T. Miyake","doi":"10.1627/JPI.64.147","DOIUrl":"https://doi.org/10.1627/JPI.64.147","url":null,"abstract":"Metal-organic frameworks (MOFs)1),2) have recently attracted much attention because of their unique properties such as crystalline and microporous structure, high thermal stability up to around 400 °C, and easy modification of pore structure and chemical properties3). Generally, MOFs consist of a multi-valent metal cation or cluster at the corner position and dior tri-carboxylic acids as the bridging unit (linker)2). MOFs with desired physical and chemical properties may be designed and synthesized by combining various metal cations and linkers. MOFs with unique properties have high potential for various applications such as adsorbents, membranes, sensors, catalysts, and others. In particular, MOFs are expected to act as lightweight hydrogen storage materials4)~6) due to their extremely high specific surface areas reaching 6000 m2 g1. Recently, MOFs have been widely studied as catalysts7),8). MOFs have also been evaluated for the separation of aromatics9),10) and aliphatic hydrocarbons11),12). p-Xylene is an important raw material for terephthalic acid, the co-monomer for polyethylene terephthalate. Nowadays, p-xylene is produced by separation from the xylene mixture by adsorption with zeolite13) or crystallization14). In the former method, xylenes diffuse into the micropores of zeolite and separation of p-xylene is based on the adsorption stability in the micropores. Multiple adsorption columns are needed for effective separation, and the feed flow is changed by the operation of many valves systematically (pseudo-transfer bed separation). Consequently, the separation process is complicated and the equipments are costly. In contrast, separation by crystallization necessitates heating and cooling of the vessel and so the energy consumption is high. Therefore, a new process to separate p-xylene at lower cost is very desirable. MOFs have been investigated for the separation of xylenes15)~25). In most cases, xylenes diffused into the micropores and separation was governed by the diffusion rate based on the molecular size of xylenes or by interactions between the MOF surface and xylenes. The separation mechanism is similar to that of the conventional process using zeolite, so the required volume of adsorbent is large because all the xylene substrate [Regular Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"36 1","pages":"147-154"},"PeriodicalIF":1.0,"publicationDate":"2021-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83018741","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Zhenglu Xiao, Shijia Chen, Longxiang Tang, Guibin Wang, Meimei Han
In recent years, important breakthroughs have been made in the exploration of the northwestern margin of Mahu sag in Junggar basin. The estimated amount of oil deposits in this region seems to be as large as 100-million-ton lithologic reservoir. A certain scale of oil reservoirs was found in the Jurassic Badaowan formation, which indicates that the Jurassic reservoir has promising prospects for exploration. The geochemical characteristics of Jurassic crude oil and Permian source rocks and oil accumulation factors are studied in this paper. The results show that carbon isotope values ( δ 13 C) and the biomarker parameters ( γ /C 30 H and C 24 Tet/C 26 TT) have a good application in oil source correlation. Crude oil in Jurassic reservoir was generated from Permian Fengcheng (P 1 f) source rock. The main hydrocarbon expulsion period of the P 1 f source rock was between late Permian and middle Cretaceous. The crude oil migrated upward into the Jurassic lithologic traps through faults or superimposed sand bodies.
{"title":"Source of the Jurassic Oil in the Western Mahu Sag of Junggar Basin, NW China","authors":"Zhenglu Xiao, Shijia Chen, Longxiang Tang, Guibin Wang, Meimei Han","doi":"10.1627/JPI.64.67","DOIUrl":"https://doi.org/10.1627/JPI.64.67","url":null,"abstract":"In recent years, important breakthroughs have been made in the exploration of the northwestern margin of Mahu sag in Junggar basin. The estimated amount of oil deposits in this region seems to be as large as 100-million-ton lithologic reservoir. A certain scale of oil reservoirs was found in the Jurassic Badaowan formation, which indicates that the Jurassic reservoir has promising prospects for exploration. The geochemical characteristics of Jurassic crude oil and Permian source rocks and oil accumulation factors are studied in this paper. The results show that carbon isotope values ( δ 13 C) and the biomarker parameters ( γ /C 30 H and C 24 Tet/C 26 TT) have a good application in oil source correlation. Crude oil in Jurassic reservoir was generated from Permian Fengcheng (P 1 f) source rock. The main hydrocarbon expulsion period of the P 1 f source rock was between late Permian and middle Cretaceous. The crude oil migrated upward into the Jurassic lithologic traps through faults or superimposed sand bodies.","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"51 1","pages":""},"PeriodicalIF":1.0,"publicationDate":"2021-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77076046","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Xin Wang, H. Gang, Jin-Feng Liu, Shi‐Zhong Yang, Bozhong Mu
With the increase in global energy demand and decrease in crude oil reserves, the technology for the enhancement of oil recovery is becoming increasingly important. Even after primary and secondary oil recovery, 60-70 % of the crude oil remains in oil reservoirs1),2). Chemical flooding technologies, including surfactant flooding3),4), polymer flooding5),6), surfactant-polymer flooding7),8), and alkaline-surfactant-polymer (ASP) flooding9),10), have been employed in different oil fields over the last few decades. Among these, ASP flooding is one of the leading technologies for tertiary oil recovery from declining oil reservoirs11),12), and has been successfully applied in several oilfields, including the Daqing, Shengli, and Xinjiang oilfields in China, with a remarkable increase of more than 20 % in oil recovery from water-flooded oil reservoirs with high water content. The most important mechanism of ASP flooding for enhancing oil recovery includes two closely correlated aspects: reduction in oil/brine interfacial tension (IFT) to an ultra-low level (≤ 103 mN/m), and improvement in the swept efficiency of flooding fluids in oil reservoirs13)~15). Evidently, a key factor for enhancing oil recovery is the decrease in oil/brine IFT to an ultra-low level (103 mN/m) at low surfactant dosage, and thus at low cost. In ASP flooding, the surfactant, i.e., petroleum sulfonate (NPS), is widely used owing to its high oil/water interfacial activity16)~18). However, to some extent, its industrial application is limited by a number of constraints. Commercial NPS is usually a mixture of sulfonates, unsulfonated oil, inorganic salts, and water19). The performances of sulfonates themselves vary significantly with the raw materials from which they are produced as well as the unpredictable production of polysulfonates20). In field applications, chromatographic [Regular Paper]
{"title":"Consideration of Application Possibility of Biosurfactant and Alkaline-surfactant-polymer (B-ASP) with Ultra-low Crude Oil/Brine Interfacial Tension for Enhancement of Oil Recovery","authors":"Xin Wang, H. Gang, Jin-Feng Liu, Shi‐Zhong Yang, Bozhong Mu","doi":"10.1627/JPI.64.84","DOIUrl":"https://doi.org/10.1627/JPI.64.84","url":null,"abstract":"With the increase in global energy demand and decrease in crude oil reserves, the technology for the enhancement of oil recovery is becoming increasingly important. Even after primary and secondary oil recovery, 60-70 % of the crude oil remains in oil reservoirs1),2). Chemical flooding technologies, including surfactant flooding3),4), polymer flooding5),6), surfactant-polymer flooding7),8), and alkaline-surfactant-polymer (ASP) flooding9),10), have been employed in different oil fields over the last few decades. Among these, ASP flooding is one of the leading technologies for tertiary oil recovery from declining oil reservoirs11),12), and has been successfully applied in several oilfields, including the Daqing, Shengli, and Xinjiang oilfields in China, with a remarkable increase of more than 20 % in oil recovery from water-flooded oil reservoirs with high water content. The most important mechanism of ASP flooding for enhancing oil recovery includes two closely correlated aspects: reduction in oil/brine interfacial tension (IFT) to an ultra-low level (≤ 103 mN/m), and improvement in the swept efficiency of flooding fluids in oil reservoirs13)~15). Evidently, a key factor for enhancing oil recovery is the decrease in oil/brine IFT to an ultra-low level (103 mN/m) at low surfactant dosage, and thus at low cost. In ASP flooding, the surfactant, i.e., petroleum sulfonate (NPS), is widely used owing to its high oil/water interfacial activity16)~18). However, to some extent, its industrial application is limited by a number of constraints. Commercial NPS is usually a mixture of sulfonates, unsulfonated oil, inorganic salts, and water19). The performances of sulfonates themselves vary significantly with the raw materials from which they are produced as well as the unpredictable production of polysulfonates20). In field applications, chromatographic [Regular Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"83 1","pages":""},"PeriodicalIF":1.0,"publicationDate":"2021-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82910655","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
H. Matsuhashi, Asako Iwamoto, Misaho Sasaki, Kana Yoshida, H. Aritani
Alkaline earth metal oxides such as MgO are well known to show activities as solid base catalysts. The preparation, active site structure, and application of MgO to numerous base-catalyzed organic reactions have been extensively investigated1)~4). Strontium oxide (SrO) has a higher base strength among the alkaline earth metal oxides, because strontium (Sr) has lower electronegativity within the group of alkaline earth metals. The base strength increases in the order MgO < CaO < SrO < BaO5),6). Therefore, SrO is expected to achieve higher catalytic activity in various organic reactions. SrO catalysts are applicable to many base-catalyzed reactions, such as aldol condensation5), nitroaldol reaction7), Michel addition8),9), Cannizzaro reaction10), transesterification11)~18), Tishchenko reaction19),20), diacetone alcohol decomposition6), and amination of alkene21). However, fewer studies have been carried out with SrO than MgO as the base catalyst, particularly the preparation and application of SrO as a base catalyst, partially because of the difficulties associated with the preparation of SrO. Alkaline earth metal oxides are usually obtained by thermal decomposition of the corresponding hydroxide or carbonate at elevated temperatures2),3). For example, Mg(OH)2 is converted to MgO by thermal decomposition around 650 K22),23). However, the melting point of Sr(OH)2 is slightly lower than the decomposition temperature of the hydroxide24). Consequently, Sr(OH)2 first melts and then decomposes as the temperature increases. The decomposition of Sr(OH)2 in the liquid phase results in solid SrO with low surface area. In contrast, thermal decomposition of SrCO3 to SrO requires very high temperatures (>1073 K) because of the high thermal stability of SrCO37),10),25)~29). Therefore, the conventional thermal decomposition method is not appropriate for SrO catalyst preparation from the hydroxide or carbonate. To overcome these problems, we investigated solid-liquid interface reaction for the preparation of SrO base catalyst. In general, a metal alkoxide with high reactivity to[Regular Paper]
众所周知，氧化镁等碱土金属氧化物具有固体碱催化剂的活性。MgO的制备、活性位点结构以及在多种碱催化有机反应中的应用已经得到了广泛的研究(1)~4)。在碱土金属氧化物中，氧化锶(SrO)具有较高的碱强度，因为在碱土金属基团中，锶(Sr)具有较低的电负性。基体强度的增大顺序为MgO < CaO < SrO < BaO5)，6)。因此，SrO有望在各种有机反应中获得更高的催化活性。SrO催化剂适用于许多碱催化反应，如醛醇缩合反应(5)、硝基醇反应(7)、Michel加成反应(8)、9)、Cannizzaro反应(10)、酯交换反应(11)~18)、Tishchenko反应(19)、20)、二丙酮醇分解(6)、烯烃胺化反应(21)。然而，与氧化镁相比，以SrO作为碱催化剂进行的研究较少，特别是SrO作为碱催化剂的制备和应用，部分原因是SrO的制备存在困难。碱土金属氧化物通常是由相应的氢氧化物或碳酸盐在高温下热分解得到的2)，3)。例如，Mg(OH)2在650 k2左右通过热分解转化为MgO(22)，23)。而Sr(OH)2的熔点略低于氢氧化物的分解温度(24)。因此，随着温度的升高，Sr(OH)2首先熔化，然后分解。Sr(OH)2在液相中的分解产生了低表面积的固体SrO。相比之下，SrCO3的热分解需要非常高的温度(>1073 K)，因为SrCO37)，10)，25)~29)具有很高的热稳定性。因此，传统的热分解方法不适用于氢氧化物或碳酸盐制备SrO催化剂。为了克服这些问题，我们研究了固液界面反应制备SrO碱催化剂。一种对[普通纸张]具有高反应性的金属醇氧化合物
{"title":"Synthesis of SrO–Al2O3 Solid Base Catalysts from Strontium Hydroxide and Aluminum Alkoxide by a Solid-liquid Interface Reaction","authors":"H. Matsuhashi, Asako Iwamoto, Misaho Sasaki, Kana Yoshida, H. Aritani","doi":"10.1627/JPI.64.103","DOIUrl":"https://doi.org/10.1627/JPI.64.103","url":null,"abstract":"Alkaline earth metal oxides such as MgO are well known to show activities as solid base catalysts. The preparation, active site structure, and application of MgO to numerous base-catalyzed organic reactions have been extensively investigated1)~4). Strontium oxide (SrO) has a higher base strength among the alkaline earth metal oxides, because strontium (Sr) has lower electronegativity within the group of alkaline earth metals. The base strength increases in the order MgO < CaO < SrO < BaO5),6). Therefore, SrO is expected to achieve higher catalytic activity in various organic reactions. SrO catalysts are applicable to many base-catalyzed reactions, such as aldol condensation5), nitroaldol reaction7), Michel addition8),9), Cannizzaro reaction10), transesterification11)~18), Tishchenko reaction19),20), diacetone alcohol decomposition6), and amination of alkene21). However, fewer studies have been carried out with SrO than MgO as the base catalyst, particularly the preparation and application of SrO as a base catalyst, partially because of the difficulties associated with the preparation of SrO. Alkaline earth metal oxides are usually obtained by thermal decomposition of the corresponding hydroxide or carbonate at elevated temperatures2),3). For example, Mg(OH)2 is converted to MgO by thermal decomposition around 650 K22),23). However, the melting point of Sr(OH)2 is slightly lower than the decomposition temperature of the hydroxide24). Consequently, Sr(OH)2 first melts and then decomposes as the temperature increases. The decomposition of Sr(OH)2 in the liquid phase results in solid SrO with low surface area. In contrast, thermal decomposition of SrCO3 to SrO requires very high temperatures (>1073 K) because of the high thermal stability of SrCO37),10),25)~29). Therefore, the conventional thermal decomposition method is not appropriate for SrO catalyst preparation from the hydroxide or carbonate. To overcome these problems, we investigated solid-liquid interface reaction for the preparation of SrO base catalyst. In general, a metal alkoxide with high reactivity to[Regular Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"9 1","pages":""},"PeriodicalIF":1.0,"publicationDate":"2021-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87249189","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Fang Zhao, Changfeng Xi, Xialin Zhang, X. Shi, Fengxiang Yang, Hetaer Mu, Wenlong Guan, Hongzhuang Wang, Hongbin Zhan, T. Babadagli, H. Li
We systematically studied the influential factors of post-steam in-situ combustion (ISC) project conducted in complex heavy oil reservoir in China using laboratory one-dimensional combustion experiments, reservoir simulation outputs, and data collected from the field application. The ISC project showed vastly different production performances in different regions of the field and two types of representative factors which acts on the whole ISC production stages were identified. As for a post-steam ISC process, oil viscosity and the pre-ISC recovery factor are the main reservoir parameters affecting the performance of ISC process and numerical model reflecting these two factors were established to analysis the production characteristics of producers. Type I group has a low oil viscosity ( ＜ 8000 mPa s) and a high steam-flooded recovery factor ( ＞ 30 %); after ISC treatment, these producers show a high initial water cut, while some experience channeling issues and hence produce a large quantity of flue gas. Type II group has a high oil viscosity ( ＞ 20,000 mPa s) and a low cyclic steam stimulation (CSS) recovery factor (15-20 %); these producers have a high air injection pressure exceeding the fracture pressure. Results show that corresponding remedial methods applied to these two well groups can effectively enhanced oil recovery.
{"title":"Analysis on the Main Influential Factors of Post-steam In-situ Combustion Performance in Heavy Oil Reservoir","authors":"Fang Zhao, Changfeng Xi, Xialin Zhang, X. Shi, Fengxiang Yang, Hetaer Mu, Wenlong Guan, Hongzhuang Wang, Hongbin Zhan, T. Babadagli, H. Li","doi":"10.1627/JPI.64.76","DOIUrl":"https://doi.org/10.1627/JPI.64.76","url":null,"abstract":"We systematically studied the influential factors of post-steam in-situ combustion (ISC) project conducted in complex heavy oil reservoir in China using laboratory one-dimensional combustion experiments, reservoir simulation outputs, and data collected from the field application. The ISC project showed vastly different production performances in different regions of the field and two types of representative factors which acts on the whole ISC production stages were identified. As for a post-steam ISC process, oil viscosity and the pre-ISC recovery factor are the main reservoir parameters affecting the performance of ISC process and numerical model reflecting these two factors were established to analysis the production characteristics of producers. Type I group has a low oil viscosity ( ＜ 8000 mPa s) and a high steam-flooded recovery factor ( ＞ 30 %); after ISC treatment, these producers show a high initial water cut, while some experience channeling issues and hence produce a large quantity of flue gas. Type II group has a high oil viscosity ( ＞ 20,000 mPa s) and a low cyclic steam stimulation (CSS) recovery factor (15-20 %); these producers have a high air injection pressure exceeding the fracture pressure. Results show that corresponding remedial methods applied to these two well groups can effectively enhanced oil recovery.","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"30 1","pages":""},"PeriodicalIF":1.0,"publicationDate":"2021-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90862030","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Asphaltene flow assurance is a critical subject during oil production and transportation in the upstream oil industry. Solid asphaltenes are precipitated and grown into aggregates that plug the pore throat of a rock formation, production tubing, surface flowlines and/or further downstream. These organic types of flow restriction are used to cause formation damage or production loss which require costly remedial measures. When the problem area is a reservoir rock surface, the issue is not only one of simple flow restriction but also of ultimate oil recovery deterioration owing to wettability alteration. Furthermore, solid asphaltene particles as nuclei can assist in forming tight emulsions that reduce oil-water separation efficiency and oil quality from the perspective of water content. The accumulation of asphaltene deposits in the surface oil-water separator is another factor that reduces separation efficiency because of periodic shut-down to remove sludge. Chemical treatment and/or facility design modification can be applied to mitigate such issues. Gas injection is a promising technique of enhanced oil recovery (EOR) that changes the composition of reservoir fluid by mixing with injection gas, which can enhance asphaltene precipitation. The risks associated with asphaltene precipitation must therefore be carefully evaluated as a part of potential gas injection application. Indeed, the increase of asphaltene risks related to gas injection is widely recognized1)~11). Because of its importance in securing asphaltene flow assurance, the author and associated research teams have conducted various asphaltene analyses12)~15). This work consistently requires some novel contrivance to understand the underlying mechanics of asphaltene behavior whereas apparent contradictions are often encountered. For example, the asphaltene onset pressure (AOP) is detectable at some locations but not others14),15), and some asphaltene deposits observed in the field have not been detected from experimental predictions13). This article is therefore motivated by the need to summarize the practical lessons learned with regards to asphaltene issues in industry. [Review Paper]
{"title":"Asphaltene Flow Assurance Risks: How Are Pitfalls Brought into the Open?","authors":"H. Yonebayashi","doi":"10.1627/JPI.64.51","DOIUrl":"https://doi.org/10.1627/JPI.64.51","url":null,"abstract":"Asphaltene flow assurance is a critical subject during oil production and transportation in the upstream oil industry. Solid asphaltenes are precipitated and grown into aggregates that plug the pore throat of a rock formation, production tubing, surface flowlines and/or further downstream. These organic types of flow restriction are used to cause formation damage or production loss which require costly remedial measures. When the problem area is a reservoir rock surface, the issue is not only one of simple flow restriction but also of ultimate oil recovery deterioration owing to wettability alteration. Furthermore, solid asphaltene particles as nuclei can assist in forming tight emulsions that reduce oil-water separation efficiency and oil quality from the perspective of water content. The accumulation of asphaltene deposits in the surface oil-water separator is another factor that reduces separation efficiency because of periodic shut-down to remove sludge. Chemical treatment and/or facility design modification can be applied to mitigate such issues. Gas injection is a promising technique of enhanced oil recovery (EOR) that changes the composition of reservoir fluid by mixing with injection gas, which can enhance asphaltene precipitation. The risks associated with asphaltene precipitation must therefore be carefully evaluated as a part of potential gas injection application. Indeed, the increase of asphaltene risks related to gas injection is widely recognized1)~11). Because of its importance in securing asphaltene flow assurance, the author and associated research teams have conducted various asphaltene analyses12)~15). This work consistently requires some novel contrivance to understand the underlying mechanics of asphaltene behavior whereas apparent contradictions are often encountered. For example, the asphaltene onset pressure (AOP) is detectable at some locations but not others14),15), and some asphaltene deposits observed in the field have not been detected from experimental predictions13). This article is therefore motivated by the need to summarize the practical lessons learned with regards to asphaltene issues in industry. [Review Paper]","PeriodicalId":17362,"journal":{"name":"Journal of The Japan Petroleum Institute","volume":"136 1","pages":""},"PeriodicalIF":1.0,"publicationDate":"2021-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77458467","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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